BPM 004 focuses on guidelines, rules and business processes for MISO's Financial Transmission Rights (FTR) and Auction Revenue Rights (ARRs). This BPM explains how to participate in the monthly auctions, as well as rules and processes necessary to participate in the auctions. The BPM also explains the criteria necessary for Market Participant participation in the auctions.

This BPM benefits readers who want answers to the following questions:

BPM 008 describes the Market Outage Rules as they pertain to MISO, Transmission Owners (TOs) and Operators, Tariff Customers and other non-MISO members within the MISO Reliability Area who serve as TOs or Generator Operators to coordinate and respond to Planned and Unplanned Outages.

This BPM benefits readers who want answers to the following questions:

What are the market rules for Outages?

What are the responsibilities for TOs/Operators and/or Generator Owners or Operators to report planned/unplanned outages?

BPM 010 describes the Models used for the Energy Management System (EMS) power system and market operations applications and Real-Time data submitted via ICCP. The Network Model is associated with the ICCS and MISO Market system applications.

This BPM benefits readers who want answers to the following questions:

BPM 011 addresses MISO's and other entities' roles and responsibilities regarding Resource Adequacy. The BPM covers the process used to ensure that LSEs serving Load in the MISO Region have sufficient Planning Resources to meet peak demand and also have an appropriate reserve margin.

This BPM benefits readers who want answers to the following questions:

BPM 012 is specific to MISO’s monthly financial settlement of transmission service under Module B of the Tariff. This BPM is intended to benefit both internal and external readers including MISO employees, MISO Transmission Owners and Customers, MPs, wholesale and retail aggregators.

This BPM benefits readers who want answers to the following questions:

BPM 017 details the process and steps involved in the dispute resolution process. MISO prepares and maintains the BPM for Transmission Settlements Billing Dispute Resolution as it relates to the procedures to follow when initiating a Transmission Settlements dispute and provides sufficient detail for Transmission Customers and Owners to have a solid understanding of the process.

This BPM benefits readers who want answers to the following questions:

What is the business process for initiating a billing dispute for Transmission Settlements?

What are the business rules and timelines for billing disputes under Transmission Settlements?

What are the roles and responsibilities of MISO for Transmission Settlements?

How do Transmission Customers / Transmission Owners and MISO interact?

BPM 018 outlines the Voltage and Reactive Power Management Process undertaken by MISO and the companies within the MISO footprint in accordance to and beyond the NERC Standards for Transmission Operations (NERC Standard TOP) and Standards for Voltage and Reactive Control (NERC Standard VAR). It examines roles and responsibilities in analyzing, maintaining, monitoring, and controlling voltage levels, reactive resources, and reactive power flows within the MISO footprint.

This BPM benefits readers who want answers to the following questions:

What are roles and responsibilities in analyzing, maintaining, monitoring and controlling voltage levels?

What are MISO's responsibilities as the Reliability Coordinator and Market Operator in order to manage and monitor voltage and reactive power?

What are the roles of the Transmission Operator and Generator Operator?

What are the Real-Time Voltage Assessment and Real-Time Voltage Contingency Analysis Processes?

BPM 020 explains the MISO regional transmission planning process which has a goal of the development of a comprehensive expansion plan that meets both reliability and economic expansion needs. The planning process identifies solutions to reliability issues that arise from the expected dispatch of Network Resources. This BPM also explains the requirements and process for the MISO Transmission Expansion Plan (MTEP).

This BPM benefits readers who want answers to the following questions:

What are the Transmission Planning Functions and Cycles?

What are the requirements for a project to be categorized in either Appendix A, B, or C of the MTEP and the process by which projects progress through these Appendices.

What are the steps involved in the Model Development process?

What are the roles of the Transmission Owner, Generation Owner, Load-Serving Entities, Transmission Customers, Regional Transmission Owners and other Stakeholder (including Regulatory Commissions) in the MTEP process?

BPM 021 provides an overview of the three general categories of prices developed by MISO Transmission Pricing: Base Transmission Service Prices, Ancillary Service Prices, and Local Balancing Authority Area Operator Cost Prices.

This BPM benefits readers who want answers to the following questions:

BPM 022 describes the qualifications and compensation of Blackstart Units that are capable of providing Blackstart Service in accordance with Schedule 33 of the Open Access Transmission, Energy and Operating Reserve Markets Tariff for MISO, Inc. (Tariff). This BPM benefits readers who want answers to the following questions:

What are the qualifications for providing Blackstart Service?

What are the technical requirements necessary for a unit to be included in the Transmission Operator’s System Restoration Plan?

What are the criteria for testing a Blackstart Unit periodically in accordance with the NERC System Restoration and Blackstart reliability standards?

What is the process for calculation, rate calculation and revenue distribution for Blackstart Service?

BPM 023 provides an overview of the Alternative Dispute Resolution process and details related to the process for alternative dispute resolution for matters arising under MISO’s Tariff, Rate Schedules and other BPMs, where applicable. This BPM benefits readers who want answers to the following questions:

BPM 025 defines the forecast methodology, the various inputs that are considered for getting the forecast, and various assumptions made regarding forecast processes wherever applicable. This BPM benefits readers who want answers to the following questions:

Where are the forecast data published and from where can they be accessed?

What are the forecast processes and who uses the forecasts?

What are the requirements for the wind generation forecast for Dispatchable Intermittent Resources (DIR) implementation?

What are the requirements for Local Balancing Authorities (LBA), Transmission Owners (TO) and Reliability Coordinator Customers?

BPM 026 provides Market Participants with the information needed to understand the purpose and application of Demand Response (DR) within the MISO Region and covers the rules, design, and operational elements governing the implementation of the various types of demand response within MISO’s Day-Ahead and Real-Time Energy and Operating Reserve Markets. The BPM also describes how demand response resources can be accredited with Planning Reserve Credits and can be dispatched to interrupt their loads during system emergencies. This BPM benefits readers who want answers to the following questions:

What are the basic concepts of Demand Response and the benefits to be derived from Demand Response?

Who is eligible to Provide Demand Response?

What are the types of Demand Response Services?

What are Demand Response Resources (DRR) and what are the qualifications for DRRs?

What is an Aggregator of Retail Customers (ARC) and what are the criteria for eligibility?

BPM 027 describes MISO’s processes for qualifying and selecting transmission developers to implement Competitive Transmission Projects and own, operate, and maintain associated Competitive Transmission Facilities. Competitive Transmission Projects and Competitive Transmission Facilities cannot be subject to a right of first refusal in accordance with the MISO Tariff, the Owners Agreement, and Applicable Laws and Regulations. This BPM benefits readers who want answers to the following questions:

BPM 029 describes MISO’s processes for determining minimum scope requirements for Competitive Transmission Line Facilities and Competitive Substation Facilities that are included within the scope of Competitive Transmission Projects. These minimum scope requirements will be specified in the Request for Proposal and will include minimum transmission line ratings, minimum substation equipment and bus load ratings, minimum circuit breaker interrupting ratings, bus configuration and position assignment constraints, and substation equipment protection requirements. This BPM also outlines requirements that must be followed by RFP Respondents in calculating transmission line ratings to be specified within the Proposals they submit in response to an issued Request for Proposal.

The BPM benefits readers who want answers to the following questions:

How does MISO determine minimum load ratings for Competitive Transmission Line Facilities?

How does MISO determine minimum load ratings for equipment and buses within Competitive Substation Facilities?